Sensitivity Study of the main petrophysical and geomechanical parameters for the CO2 storage capacity estimation in deep saline aquifers

Transcription

1 Sensitivity Study of the main petrophysical and geomechanical parameters for the CO2 storage capacity estimation in deep saline aquifers Researcher: Laura Mª Valle, IPf* Supervisors: Ramón Rodríguez, UPM*, Marc Fleury, IFP* GERG Academic Network Event, Brussels (Belgium) June 3-4th 2010 *IPf: Petrophysical Institute Foundation *UPM: Polytechnical University of Madrid *IFP: Institute Français du Petrole

2 OVERVIEW OF PRESENTATION CO 2 NATURAL CYCLE CLIMATE CHANGE CARBON CAPTURE SEQUESTRATION WHERE TO STORE THE CO 2? PETROPHYSICAL INSTITUTE FOUNDATION HOW TO CARACTERIZE A STORAGE WHAT IS THE MATTER WITH STORAGE CAPACITY CALCULATION? CO2 STORAGE CAPACITY ESTIMATION SIMULATIONS FUTURE WORKS

3 CO2 NATURAL CYCLE

4 WHY CO2 CAPTURE AND SECUESTRATION CO2 EMISSION FROM COMBUSTION Kg CO2/Gj From Sigma Xi, the Scientific Research Society Coal Coal fuel-oil diesel NG

5 CLIMATE CHANGE Climate change Fossil fuels energy production Transport Greenhouse effect gases Industrial Processes Housing Tourism Agriculture Cut global emissions to equivalent CO2 tones by 2020 Spain: Cut 50-85% in CO2 equivalent emissions by 2050 compared to 2000, from tones under CO2 tones

6 CARBON CAPTURE SEQUESTRATION

7 CARBON CAPTURE SEQUESTRATION

8 CARBON CAPTURE SECUESTRATION CIUDEN Compostilla Technological support

9 WHERE TO STORE THE CO2? The study of Spanish geological formations began in 2003, in order to determine the ones which could storage the CO2 in safe conditions

10 PETROPHYSICAL INSTITUTE FOUNDATION Laboratory tests IPf established in 2008 PARTNERS Institute Français ais du Petrole Gas Natural SDG, S.A. Enagás, S.A. Fundación n Gómez G Pardo Placed in the South Technological Área (TecnoGetafe), within the Scientific and Technological Park, UPM.

11 PETROPHYSICAL INSTITUTE FOUNDATION Departments R.C.A.L. S.C.A.L. PVT module. Rocks Mechanism Simulation.

12 PETROPHYSICAL INSTITUTE FOUNDATION Petrophysical features of samples: Homogeneity Porosity Permeability (absolute, relative) Formation factor Saturation Mineralogy Diffusion Capillary pressure Under surface or underground conditions Reactive flow studies With CO 2 and water injection, establishing process features before and after injection, preparing models and process simulations.

13 PETROPHYSICAL INSTITUTE FOUNDATION Exploration-Exploitation Exploitation of oilfields by establishing the petrophysical features of the area and through numerical simulations Geological storage of natural gas and CO 2 sequestration by characterizing geological formations New industrial and construction materials, providing the capability to establish physical and petrophysical characteristics cs The transfer of technology, training and awareness

14 PETROPHYSICAL INSTITUTE FOUNDATION Other projects: New cell injection test for miniplugs permeability measurements Evaluation and interpretation of prolonged injection for tertiary recovery Minimum miscibility pressure estimation between two fases, under multiplecontact low movement Fluid-rock interactions and alterations in EOR operations Wells and near-fields behavior at the fluid inyection Petrophysical characterization and electric parameters calculation of storage formations

15 HOW TO CHARACTERIZE A STORAGE GEOLOGICAL INFORMATION OF THE ZONE ESTABLISH STORAGE/SEAL CAPACITY CALCULATION CARTOGRAPHY VOLUME CALCULATION TOPOGRAPHY DATES GEOLOGICAL DATES SELECTION OF THE AREA DIGITALISATION STATIC MODEL DYNAMIC MODEL STATISTICAL METHODS 3D MODEL

16 WHAT IS THE MATTER WITH STORAGE CAPACITY CALCULATION? Many of the contradictory assessments and errors in calculated storage capacity WHY? Make quick assessments with limited or no data. Estimates are wrong WHY? Need to clearly state the limitations that existed at the time of making the assessment Need to indicate the purpose and future use to which the estimates should be applied A set of guidelines for estimation of storage capacity WHY? Need to greatly assist future deliberations by government and industry on the appropriateness of geological storage of CO2 in different geological settings and political jurisdictions

17 CO2 STORAGE CAPACITY ESTIMATION GEOLOGICAL ASSUMPTION: DEEP SALINE ACUIFER Considering pore volume formula V P = S. h u. Ø. (1 S wi ) Considering volume of hydrocarbon in place formula N = V R. h u /h t. Ø. (1 S wi )/B

18 ESTIMATION OF HIDROCARBON IN PLACE R. Cosse RESERVOIR BOUNDARIES CAP ROCK Geology, geophysics, driling BASE(S) OF ACCUMULATION(S): HC/W and O/G interface(s) Well tests, logs, analysis of capillary mechanisms in cores FRACTION OF ROCK VOLUME OCCUPIED BY FLUIDS (porosity) Core analysis, logs DISTRIBUTION OF FLUIDS IN THE PORES (saturation) Analysis of capillary mechanisms in cores, logs DOWNHOLE/SURFACE RELATIONSHIP (HC volumes in initial Reservoir conditions /HC volumes in reference surface conditions) PVT laboratory analysis of represenative samples of fluids Pore Volumen Vp Volumen occupied by oil + gas or gas Vp (1 S wi ) Volumen of storage oil and/or standard gas Vp (1 S wi )/B

19 PORE VOLUME CSLF (Carbon Sequestration Leadership Forum) and NETL (National Energy Technology Laboratory), the storage capacity is define as: C= area * thickness* porosity (effective) * storage efficiency CIEMAT - Geological CO2 storage: capacities estimation methodology. Antonio Hurtado Bezos Q = V t * Φ * ρ CO2 * h st ρ CO2 = pure CO2 density at storage conditions h st = regional effectiveness Direct result of the CO2/water movement processes

20 PORE VOLUME CO2 density depending on the depth and temperature range for the surface between 7 and 18ºC CO2 density(kg/m3) Depth (km) The Pc line represents the critical pressure value

21 WHAT HAPPENS? Considering pore volume formula V P = S. h u. Ø. (1 S wi ) Necessary step but this approach is much too simple and may overstimate at least by an order of magnitude the real storage capacity of the formation envisaged for CO2 storage Estimates of storage capacity must take into account: 1. the range of trapping mechanisms that are possible at each site, 2. the different geological constraints on each mechanisms, 3. and the fact that different trapping mechanisms operate on different time scales that range from instantaneous to tens of thousands of years. * * CO2 storage capacity estimation: Issues and development of standars. Bradshaw J., Bachu S., Bonijoly D., Burrus R., Holloway S., Christensen N. P., Mathiassen O. M.

22 CO2 GEOLOGICAL- STORAGE MECHANISMS Operating time frame of various CO2 geological-storage mechanisms (modified from IPCC, 2005).

23 A VERY DELICATE MATTER TECHNO-ECONOMIC MATTER CO2 storage capacity estimation: Issues and development of standars. Bradshaw J., Bachu S., Bonijoly D., Burrus R., Holloway S., Christensen N. P., Mathiassen O. M.

24 CASE STUDY GENERAL APROACH: Calculating the storage capacity taking into account petrophysical and geomechanical parameters STEPS TO FOLLOW: Geological assumption DEEP SALINE ACUIFER Characteristics Simulation Variation of storage and injected CO2 parameters Laboratory tests Parameters measurements used in simulation

25 SIMULATORS SIMULATORS IN POLYTECHNIC UNIVERSITY OF MADRID AND PETROPHYSICAL INSTITUTE FOUNDATION Eclipse 100, Schlumberger, 2005 TOUGH2 Earth Sciences Division, Lawrence Berkeley National Laboratory University of California, Berkeley, California 1999 TOUGH2: for storage capacity (multiphase flow and multicomponent transportation of CO2 and brine) ECO2N: for CO2 dissolution in aquifers TOUGHREACT: mineralization PETRASIM Commercial version of TOUGH2. Manhattan 2007

26 SIMULATIONS MODEL SETUP: 1. Geometrically complex and heterogeneous three dimensional geologic model originally designed as a test case for oil production forecasting under uncertainty was chosen to represent a deep saline acuifer 2. The aquifer is initially fully brine-saturated, assuming a hydrostatic fluid pressure distribution. 3. Geothermal gradient has been taken into account 4. Brine compressibility is intrinsically taken into account in terms of density variation with fluid pressure

27 SIMULATIONS MODEL SETUP TWO WELLS: 1. PRODUCER-WATER 2. INJECTOR-CO2 The injected CO2 displace an equivalent volume of native brine

28 ACUIFER PARAMETERS WATER IN PLACE POROSITY

29 CO2 PARAMETERS Aproximated CO2 volume at ground level 1000m 3 Ground level Carbon dioxide gas transition to a supercritical state CO2 -gas Critical depth (aprox) Compression decreases under this depth CO2 - supercritical

30 SIMULATIONS RUNS Varying the irreductible water saturacion AQUIFER PARAMETERS Varying the relative permeability curves Varying the aquifer compressibility CO2 PARAMETERS Impact of relative permeability hysteresis on geological CO2 storage Varying CO2 viscosity with pressure

31 RESULTS FROM SIMULATIONS Varying aquifer parameters Less compressibility SATURATION Ref. compressibility The quantity of water in place remains equal in the three cases More compressibility ROCK COMPRESSIBILITY

32 RESULTS FROM SIMULATIONS Three different realtive permeability cases RELATIVE PERMEABILITY CASE 1 RELATIVE PERMEABILITY CASE 2 1,2 0,7 relative permeability 1 0,8 0,6 0,4 0, ,1 0,2 0,3 0,4 0,5 0,6 0,7 0,8 0,9 1 water saturation Krw Krg relative permeability 0,6 0,5 0,4 0,3 0,2 0, ,1 0,2 0,3 0,4 0,5 0,6 0,7 0,8 0,9 1 water saturation Krw Krg RELATIVE PERMEABILITY CASE 3 1,2 1 0,8 0,6 0,4 Krw Krg 0, ,1 0,2 0,3 0,4 0,5 0,6 0,7 0,8 0,9 1

33 RESULTS FROM SIMULATIONS THE RESULT FOR THREE DIFFERENT REALATIVE PERMEABILITY CASES The quantity of water in place remains equal in the three cases

34 RESULTS FROM SIMULATIONS Varying CO2 parameters Top of aquifer Two lower positions Impact of relative permeability hysteresis on geological CO 2 storage. Juanes R., Spiteri, E.J., Orr Jr. And Blunt M.J. 2006

35 LABORATORY TESTS Spanish Reserves for CO 2 storage Key State Reserves

36 UPM-IPf THANK YOU FOR YOUR ATTENTION